System and Method of Assessing a Wellbore Servicing Fluid or a Component Thereof

ABSTRACT

A method of assessing a wellbore servicing fluid or a component thereof comprising providing a plurality of test organisms, dividing the plurality of test organisms into a control group and at least one test group, subjecting the at least one test group to the wellbore servicing fluid or component thereof for a predetermined duration, wherein subjecting the at least one test group to the wellbore servicing fluid or component thereof comprises providing a wellbore fluid testing system comprising a plurality of containers and a cover, placing at least a portion of the control group within a first container, placing at least a portion of the at least one test group within a second container, and covering the first container and the second container with the cover, and assessing the acceptability of the wellbore servicing fluid or component thereof.

CROSS-REFERENCE TO RELATED APPLICATIONS

Not applicable.

STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT

Not applicable.

REFERENCE TO A MICROFICHE APPENDIX

Not applicable.

BACKGROUND

Hydrocarbons, such as oil and gas, are often produced from wells that penetrate hydrocarbon-bearing subterranean formations or portions thereof. Conventionally, a subterranean formation is prepared for the production of oil and/or gas therefrom by drilling a wellbore into the subterranean formation. During the drilling operation, a drilling fluid is circulated through the wellbore to remove cuttings and cool and lubricate the drilling apparatus. After the wellbore has been drilled to a preferred depth, it is common to complete the wellbore by cementing a casing string within the wellbore. Cementing is conventionally accomplished by pumping a cementitious composition into an annular space between the casing and wellbore walls and allowing the composition to set in place.

Further, completed, partially completed, and/or uncompleted wellbores are often serviced by stimulation operations to improve the recovery of hydrocarbons therefrom. Such stimulation operations include hydraulic fracturing operations, acidizing treatments, perforating operations, or the like. Stimulation operations often involve introducing various wellbore servicing fluids into at least some part of the subterranean formation at various rates, pressures, and/or amounts.

Further still, other wellbore servicing operations may be necessary throughout the service life of a wellbore and thereafter, for example, clean-out operations, fluid-loss control operations, a well containment operation, a well-kill operation, or the like. Similarly, such additional servicing operations may also entail introducing servicing fluids into the subterranean formation, for example, to increase production from the wellbore, to isolate a zone or segment of the subterranean formation, to cease the production of fluids from the subterranean formation, or for some other purpose.

Therefore, as will be appreciated by one of skill in the art, during the life of a well, many of the operations performed with respect to a wellbore involve the introduction of various fluids into the wellbore and/or the subterranean formation. The introduction of fluids presents the opportunity for such fluids to enter the environment, such as, by mixing and/or intermingling with fluids that may be present within the formation, for example, groundwater. In addition, when wellbores are drilled into a formation beneath a body of water, such as a lake, sea, or ocean, there is also the opportunity for wellbore fluids to become mixed with that water. Thus, because wellbore fluids may come into contact with the environment, it is necessary to assess the environmental impact associated with any such fluids and/or the components thereof prior to utilizing the wellbore fluid and to ensure such fluid can safely be employed for its intended purpose.

Accordingly, there exists a need for a method and/or system for assessing the environmental impact of a wellbore servicing fluid or a component thereof.

SUMMARY

Disclosed herein is a method of assessing a wellbore servicing fluid or a component thereof comprising providing a plurality of test organisms, dividing the plurality of test organisms into a control group and at least one test group, subjecting the at least one test group to the wellbore servicing fluid or component thereof for a predetermined duration, wherein subjecting the at least one test group to the wellbore servicing fluid or component thereof comprises providing a wellbore fluid testing system comprising a plurality of containers and a cover, placing at least a portion of the control group within a first container, placing at least a portion of the at least one test group within a second container, and covering the first container and the second container with the cover, and assessing the acceptability of the wellbore servicing fluid or component thereof.

BRIEF DESCRIPTION OF THE DRAWINGS

For a more complete understanding of the present disclosure and the advantages thereof, reference is now made to the following brief description, taken in connection with the accompanying drawings and detailed description:

FIG. 1 is a diagram of an embodiment of a wellbore fluid assessment method; and

FIGS. 2A-2C are schematic of an embodiment of a wellbore fluid testing system.

DETAILED DESCRIPTION OF THE EMBODIMENTS

In the drawings and description that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawing figures are not necessarily to scale. Certain features of the invention may be shown exaggerated in scale or in somewhat schematic form and some details of conventional elements may not be shown in the interest of clarity and conciseness. The present invention is susceptible to embodiments of different forms. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is not intended to limit the invention to the embodiments illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.

Unless otherwise specified, use of the terms “connect,” engage,” “couple,” attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described.

Unless otherwise specified, use of the terms “up,” “upper,” “upward,” “up-hole,” “upstream,” or other like terms shall be construed as generally from the formation toward the surface or toward the surface of a body of water; likewise, use of “down,” “lower,” “downward,” “down-hole,” “downstream,” or other like terms shall be construed as generally into the formation away from the surface or away from the surface of a body of water, regardless of the wellbore orientation. Use of any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical axis.

Unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.

Disclosed herein are embodiments of methods, and the associated apparatuses and systems, of assessing the environmental impact of a wellbore servicing fluid or a component thereof. Referring to FIG. 1, an embodiment of a wellbore fluid assessment (WFA) method 1000 is illustrated in schematic form. In the embodiment of FIG. 1, the WFA method 1000 generally comprises the steps of providing test organisms 110, dividing the test organisms into a control group and at least one test group 120, subjecting the at least one test group to a wellbore servicing fluid or a component thereof 130, and assessing the acceptability of the wellbore servicing fluid and/or the wellbore servicing fluid component 140. Also disclosed herein is a method of servicing a wellbore. In an embodiment, such a wellbore servicing method generally comprises, after assessing the acceptability of a wellbore servicing fluid or a component thereof, for example, as by the WFA method disclosed herein, communicating the wellbore servicing fluid and/or a wellbore servicing fluid comprising the wellbore servicing fluid component into a wellbore.

In an embodiment, the step of providing the test organisms 110 generally comprises any suitable process and/or combination of processes by which a suitable number of one or more suitable test organisms is made available for use in the remainder of the WFA method 1000. In an embodiment, the step of providing the test organisms may generally comprise the sub-steps of culturing a population of test organisms and selecting organisms for use in the WFA method 1000 from the population of test organisms.

In an embodiment, a suitable test organism may be characterized as an aquatic and/or marine organism. Additionally, in an embodiment a suitable test organism may be an organism whose suitability for testing is dependent upon size and/or life stage. As used herein, the term test organism may refer to any suitable organism at any life stage.

In a particular embodiment, the test organism may comprise a member of the order Mysida. Mysida is an order of small, shrimp-like crustaceans within the super-order of Peracarida. Mysida are also commonly referred to as “opossum shrimps.” Generally, such a member of the species of Mysida may be characterized as being from about 5 to about 25 millimeters in length and varying in color from pale or nearly transparent to bright orange or brown. Many members of Mysida may be characterized as omnivorous, for example, generally feeding on algae and/or zooplankton. Alternative examples of a suitable test organism include, but are not limited to, Pimephales promelas (e.g., a freshwater minnow), Cyprinodon vareigatus (e.g., a saltwater minnow), and Leptocheirus plumulosus (e.g., an amphipod).

In an embodiment, the test organisms may be provided and/or present within a suitable fluid and/or composition, referred to herein as an environmental fluid. In such an embodiment, the environmental fluid in which the test organisms are provided generally refers to a fluid and/or composition that is substantially similar to the natural environment of a given test organism. For example, in various embodiments, the test organisms may be provided within an aqueous solution (e.g., water). In an embodiment, the aqueous solution may comprise sediment (e.g., mud), as may be appropriate for a given organism. For example, some test organisms may dwell within the sediment beneath a volume of water. In an embodiment where the test organisms are provided within such an aqueous solution (e.g., water and/or mud), the water (and/or the water used to form the mud) may be characterized as any suitable wholly and/or substantially aqueous fluid. In such an embodiment, such a substantially aqueous fluid comprises less than about 50% nonaqueous component(s), alternatively less than about 45%, 40%, 35%, 30%, 25%, 20%, 15%, 10%, 5%, 4%, 3%, 2% or 1% nonaqueous component(s). In an embodiment, the water may comprise an inorganic monovalent salt, an inorganic multivalent salt, or both. Nonlimiting examples of salts as may be present within the water include water-soluble chloride, bromide and carbonate, hydroxide and formate salts of alkali and alkaline earth metals, zinc bromide, and combinations thereof. The salt or salts in the water may be present in an amount ranging from greater than about 0.01% by weight to a saturated salt solution. In a particular embodiment, the salt or salts in the water may be present in an amount ranging from about 5% to about 25% by weight; alternatively, about 20% by weight. In an alternative embodiment, the salinity may range from about 15 ppt. to about 40 ppt.

In an embodiment, a test organism culturing and/or separation (TOCS) system may be utilized in the step of providing the test organisms 110, particularly, for use in one or more of the sub-steps of culturing a population of test organisms and of selecting organisms for use in the WFA method 1000, is illustrated. Examples of suitable such TOCS systems are disclosed in U.S. application Ser. No. 13/527,373 to Mohar and U.S. application Ser. No. 13/526,049 to Trickey, each of which is incorporated herein by reference in its entirety. Alternative systems may be appreciated by one of skill in the art upon viewing this disclosure.

In an embodiment, a suitable number of test organisms of a given size range and/or life stage may be selected and/or prepared for testing. For example, as may be appreciated by one of skill in the art viewing this disclosure, the size and/or number of test organisms that will be suitable for a given test procedure may vary depending upon a variety of factors, such as, the number of trials to be performed, the duration of the trials, the type of wellbore fluid or wellbore fluid component to be assessed, the means by which the fluid is to be assessed (e.g., as will be discussed herein below) or the like. In an embodiment, the test organisms not selected for usage in the trials, as will be described herein below, may be returned to a suitable culturing environment, and/or utilized as brood stock for continued culturing of such test organisms, or the like.

In an embodiment, the test organisms selected for usage in the trial(s) may be divided into a plurality of groups comprising a control group and one or more test groups. For example, in various embodiments the test organisms, for a given trial, may be divided into a control group and one, two, three, four, five, or more test groups. In such an embodiment, each of the plurality of test groups may be used to test varying concentrations of the wellbore servicing fluid and/or component, different components of a single wellbore servicing fluid, or the like. As referred to herein, the wellbore servicing fluid and/or component generally refers to a fluid (e.g., a composite fluid comprising multiple components) or one or more components thereof, which may be similar in composition, concentration, or combinations thereof, to a fluid as may be employed in the performance of a wellbore servicing operation, for example, a drilling fluid, a wellbore clean-out fluid, a completion and/or cementing fluid, an acidizing fluid, a perforating fluid, a fracturing or other stimulation fluid, a workover fluid, a shut-in or well-kill fluid, and/or any other like, suitable fluid.

For example, a plurality of test groups may be utilized to test the acceptability of a given servicing fluid and/or a given servicing fluid component at various concentrations, for example, at about 20%, 40%, 60%, 80%, 100%, and/or 120%, respectively, of the concentration at which that fluid and/or component may be employed. In another embodiment, a plurality of test groups may be utilized to test the acceptability of various servicing fluid components and/or combinations of components, for example, of Component A, Component B, Component C, and Component D, etc., respectively, of a given servicing fluid.

As will be appreciated by one of skill in the art viewing this application, each trial may be performed in multiple iterations, for example, to improve the accuracy and/or statistical significance of any such trials. For example, the trials, as disclosed herein, may be performed in duplicate, triplicate, quadruplicate, etc. In such an embodiment, one of skill in the art will appreciate that the number of test organisms necessitated by such multiple trial iterations will increase, correspondingly.

In an embodiment, the at least one test group may be subjected to a given servicing fluid and/or a given servicing fluid component, for example, as disclosed herein. Referring to FIGS. 2A, 2B, and 2C, embodiments of a wellbore fluid testing (WFT) system 2000, for example, as may be employed in the step of subjecting the at least one test group to a wellbore servicing fluid and/or a component thereof, is illustrated. In the embodiment of FIGS. 2A, 2B, and 2C, the WFT system generally comprises a plurality of test containers 210 and a cover 220 configured to selectively allow access to one or more of the plurality of containers 210.

In an embodiment, each of the plurality of containers 210 may comprise a suitable type and/or configuration. Such test containers may be selected based upon factors including, but not limited to, the test organism that was selected, the size of the test organisms, the number of test organisms, the duration of the trial, the suitability of the environment provided by the test container for the test organisms, the type of fluid and/or material being tested, the amount of fluid and/or material to be tested, the like, and combinations thereof. Depending upon such factors, examples of suitable test containers may include, but are not limited to, petri dishes, jars of various sizes and configurations, trays, tubs, barrels, and the like. In an embodiment, each of the plurality of containers may be suitably-sized. For example, a given container may generally enclose a chamber having an associated volume (e.g., fluid volume) in a range of from about 0.25 liters to about 5 liters, alternatively, from about 0.5 liters to about 2 liters, alternatively, about 1 liter. Also, in an embodiment, each of the plurality of containers may be formed from a suitable material. Examples of such materials include, but are not limited to glass, plexi-glass, plastic, a phenolic material, metal, rubber, acrylic glass (e.g., poly(methyl methacrylate) or “PMMA”), a polycarbonate resin thermoplastic (e.g., Lexan®), or combinations thereof. In an embodiment, each of the plurality of containers 210 may be characterized as transparent, alternatively, substantially transparent, alternatively, translucent, alternatively, substantially opaque, alternatively, opaque.

In an embodiment, the containers 210 may be present in any suitable number and/or configuration. For example, while in the embodiment of FIGS. 2A, 2B, and 2C the WFT system comprises 18 containers 210, for example, being arranged in six columns of three containers each (e.g., six columns and three rows), one of skill in the art, upon viewing this disclosure, will recognize that a WFT system may comprise 6, 8, 10, 12, 15, 20, 24, 25, 28, 30, 36 or any other suitable number of containers. Additionally, one of skill in the art, upon viewing this disclosure will also recognize that such containers may be provided in any suitable number of columns, each column having any suitable number of containers, for example, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15 or more columns, each having 2, 3, 4, 5, 6, 7, 8, 9, 10, or more containers. Further still, while in the embodiment of FIGS. 2A, 2B, and 2C each of the columns comprises the same number of containers, in an alternative embodiment, various rows and/or columns may have varying numbers of containers.

In an embodiment, the cover 220 may be generally configured to cover and/or substantially enclose each of the plurality of containers 210. In an embodiment, the cover 220 may comprise any suitable size, shape, and/or configuration. For example, in the embodiment of FIGS. 2A, 2B, and 2C, the cover generally comprises a plate of a suitable material. In an embodiment, the cover may be formed from glass, plexi-glass, plastic, a phenolic material, acrylic glass (e.g., poly(methyl methacrylate) or “PMMA”), a polycarbonate resin thermoplastic (e.g., Lexan®), or combinations thereof. Also, the cover 220 may be characterized as transparent, alternatively, substantially transparent, alternatively, translucent, for example, so as to allow light to reach the containers 210 (e.g., the chamber being generally defined by each of the containers 210). In an embodiment, the cover 220 may be of a suitable thickness. For example, the cover 220 may have a thickness in the range of from about 0.25 cm to about 4 cm, alternatively, from about 0.5 cm to about 3 cm, alternatively, from about 1 cm to about 2 cm.

In an embodiment, the cover 220 may be sized and/or shaped appropriately to cover each of the plurality of containers 210. For example, in various embodiments, the size and or shape of a cover like cover 220 may be dependent upon the number of containers the cover is meant to accommodate, the arrangement (and/or potential arrangements) of the containers, the spacing between the containers, or combinations thereof. For example, in the embodiment of FIGS. 2A, 2B, and 2C, the cover 220 is generally rectangular. In an alternative embodiment, a cover may be shaped substantially as a square, an oval, a circle, a triangle, or any other suitable shape.

In an embodiment, the cover 220 may be configured to selectively allow access to one or more of the containers 210. For example, in the embodiment of FIGS. 2A, 2B, and 2C, the cover 220 comprises a plurality of openings 228 (e.g., holes, ports, or the like). For example, in an embodiment, each of the openings 228 may be sized suitably so as to allow an aeration tube to be inserted therethrough, for example, such that the aeration tube rests within a respective container. Additionally, the openings 228 may allow for access to a respective container, for example, with a pipette or the like, for example, for the purpose of sampling the contents of a container, providing food or nutrients, adding environmental fluid to the container, or combinations thereof.

In an additional or alternative embodiment, the cover 220 comprises two or more portions joined by a hinge 225, allowing selective access to a portion of the containers 210. For example, as illustrated in the embodiment of FIG. 2B, the hinge 225 allows a first portion 220 a to be easily lifted, for example, allowing access to a first row of containers 210. In an alternative embodiment, a hinge may be positioned to allow access to two or more rows, or any other suitable portion of the containers 210. In an embodiment, the hinge 225 may comprise any suitable type or configuration of hinge or hinges, for example, as will allow at least a portion of the cover 220 to be flexed or partially rotated. For example, the hinge 225 may comprise a plurality of small hinges (such as a plurality of barrel hinges, pivot hinges, flag hinges, butt and mortise hinges, case hinges, strap hinges, the like, or combinations thereof), alternatively, a single larger hinge (e.g., a flap), or any other suitable configuration.

In still another additional or alternative embodiment, the cover 220 may be configured to raised and/or lowered via a lift. For example, referring to FIG. 2C, in an embodiment the cover 220 is configured to be raised and/or lowered via lift comprising a hoist system 230. In the embodiment of the hoist system 230 generally comprises a plurality of pulleys 232 (for example, which may be suspended from a platform or other overhead support or framework) and one or more lines 231, such as a rope, cord, string, belt, cable, braid, band, or the like. In an embodiment, the lift (e.g., the hoist of FIG. 2C) may be configured so as to allow the cover 220 to be lifted, for example, by retracting the line 231 and/or to allow the cover 220 to be lowered (e.g., returned) to the original position by letting out the line 231 (such as by hand or, alternatively, via the operation of a motor-driven winch or the like). Alternative embodiments of a suitable lift may be appreciated by one of skill in the art upon viewing this disclosure. In an embodiment, for example, in the embodiment of FIG. 2C the hinge 225 is optional and, when present, may work cooperatively and/or in conjunction with the lift. For example, the hinge 225 may have a locked and/or unlocked configuration so as to enable the lift to selectively raise either a portion of the cover 220 or the entirety of the cover 220.

In an embodiment, each of the control group and the one or more test groups may be placed in separate, suitable containers for the duration of the trials. For example, in an embodiment where a WFT system like WFT system 2000 is employed in the step of subjecting the at least one test group to a wellbore servicing fluid and/or a component thereof, the control group may be placed in one or more of the plurality of containers 210 (for example, within all of the containers of a particular column or a particular row) and the at least one test group may be placed in one or more of the plurality of containers 210 (for example, with all of the containers in one or more columns or one or more rows).

As disclosed above, in an embodiment a plurality of test groups may be utilized to test the acceptability of a given servicing fluid and/or a given servicing fluid component at about 20%, 40%, 60%, 80%, 100%, and/or 120%, respectively, of the concentration at which that fluid and/or component may be employed. For example, in such an embodiment where a WFT system like WFT system 2000 is employed, a first column/row of containers may comprise the control group, a second column/row of containers may comprise test organisms subjected to a first concentration of the servicing fluid (e.g., 20% conc.), a third column/row of containers may comprise test organisms subjected to a second concentration of the servicing fluid (e.g., 40% conc.), a fourth column/row of containers may comprise test organisms subjected to a third concentration of the servicing fluid (e.g., 60% conc.), a fifth column/row of containers may comprise test organisms subjected to a fourth concentration of the servicing fluid (e.g., 80% conc.), and a sixth column/row of containers may comprise test organisms subjected to a fifth concentration of the servicing fluid (e.g., 100% conc.).

As also disclosed above, in another embodiment, a plurality of test groups may be utilized to test the acceptability of Component A, Component B, Component C, Component D, and Component E, etc., respectively, of a given servicing fluid. For example, in such an embodiment where a WFT system like WFT system 2000 is employed, a first column/row of containers may comprise the control group, a second column/row of containers may comprise test organisms subjected to a first component of the servicing fluid (e.g., component A), a third column/row of containers may comprise test organisms subjected to a second component of the servicing fluid (e.g., component B), a fourth column/row of containers may comprise test organisms subjected to a third component of the servicing fluid (e.g., component C), a fifth column/row of containers may comprise test organisms subjected to a fourth component of the servicing fluid (e.g., component D), and a sixth column/row of containers may comprise test organisms subjected to a fifth component of the servicing fluid (e.g., component E). Upon viewing this disclosure, one of ordinary skill in the art will appreciate suitable alternative configurations as may be employed via a WFT system, as disclosed herein.

As noted above, in an embodiment the control group and the test group may be provided in a suitable environmental fluid (e.g., an aqueous fluid and/or mud). In an embodiment, the test group or groups of the test organisms may be subjected to the wellbore servicing fluid or a component thereof, for example, by introducing the wellbore servicing fluid and/or component into the environmental fluid.

In an embodiment, each of the one or more test groups may be placed in the environmental fluid, along with the servicing fluid and/or servicing fluid component in a specified concentration, within the test container for a suitable duration. Similarly, the control group may be placed in the environmental fluid within the test container for the same duration. For example, in an embodiment where a WFT system like WFT system 2000 is employed each of the control and test groups may be placed in the containers 210 for such a duration. In an embodiment, such a suitable duration may be about 24 hours, alternatively, about 48 hours, alternatively, about 72 hours, alternatively, about 96 hours, alternatively, about 5 days, alternatively, about 7 days, alternatively, about 10 days, alternatively, about 12 days, alternatively, about 15 days, alternatively, about 28 days.

In an embodiment, the environment within each of the test containers may be maintained as will be suitable for the selected test organism. For example, in various embodiments, maintaining such a suitable environment may include maintaining a suitable temperature (e.g., about 20° C.), maintaining the salinity of the environmental fluid within a suitable range (e.g., about 29-36% salinity when utilizing Mysida, however salinity may varies with species, as will be appreciated by one of skill in the art upon viewing this disclosure), maintaining the oxygen saturation of the environmental fluid within a suitable range (e.g., via aeration), provision of food sources and/or nutrients, or combinations thereof. For example, in an embodiment where a WFT system like WFT system 2000 is employed, aeration (e.g., oxygen) may be provided via a plurality of aeration tubes (e.g., bubblers) inserted or fitted through the holes 228 within the cover 220. Similarly, food and/or nutrients may be introduced into the containers (for example, once, twice, three time, four times, five times, or more, daily, for the duration of the test).

Further still, in an embodiment where a WFT system like WFT system 2000 is employed, during the duration of the test, the containers 210 (or a portion thereof) may be inspected and/or sampled. For example, the hinged cover 220 allows for access to a portion of the containers; additionally or alternatively, a lift system like the hoist system 230 allows for access to all of the containers 210. In various embodiments, a WFT system, for example, as disclosed herein, may be advantageously employed in the performance of a testing method, as also disclosed herein, for example, by reducing the possibility or likelihood of contamination of one or more of the containers (for example, as could result from transferring materials between containers where the cover is not returned to the same position).

In an embodiment, the acceptability of the wellbore servicing fluid and/or the wellbore servicing fluid component may be assessed upon completion of the trial (e.g., at the termination of the desired duration). In an embodiment, assessing the acceptability of the fluid and/or the fluid component may comprise assessing the health of the test organisms of the at least one test group and assessing the health of the test organisms of the control group. In such an embodiment, assessing the health of the test organisms may comprise observing the survival rate associated with each group, observing the reproduction rate associated with each group, the rate of weight change associated with each group, observing various qualitative and/or quantitative characteristics associated with test organisms of each group, or combinations thereof.

In an embodiment, assessing the acceptability of the fluid and/or the fluid component may further comprise comparing the control group with the test groups. In various embodiments, the control group and the test groups may be compared to determine whether any statistically significant difference, in any one or more of the observed characteristics, qualities, or quantities, may be due to the presence of the wellbore servicing fluid or any component thereof at any of the tested concentrations. In an embodiment, various statistical methods may be employed to determine the significance of any apparent or unapparent difference between the control group and any one or more of the test groups.

In an embodiment, the wellbore servicing fluid and/or a component thereof may be deemed acceptable where no statistically significant difference exists between the control group and one or more of the test groups, depending upon the test group. For example, a wellbore servicing fluid and/or component may be deemed acceptable for use at some concentrations and unacceptable at other concentrations. Alternatively, the wellbore servicing fluid and/or a component thereof may be deemed acceptable where the differences between the control group and one or more of the test groups are not detrimental to the test organisms (e.g., where the wellbore servicing fluid and/or component has a beneficial effect on the test organisms).

In various embodiments, assessing the acceptability of the fluid and/or the fluid component may comprise determining a median lethal concentration (an LC50), a median effective concentration (an EC50), a median inhibitory concentration (an IC50), a no observed effect concentration (NOEC), a lowest observed effect concentration (a LOEC), or combinations thereof. As used herein, the term “LC50” may refer to the concentration of a test substance where 50% of the organisms die; the term “EC50” may refer to the concentration of a test substance where 50% of the organisms show a significant given effect (e.g., if a skin test, where half the organisms show the expected rash or response); the term “IC50” may refer to the concentration of a test substance where 50% of the organisms given response is inhibited (e.g., where production stops); the term “NOEC” may refer to the highest concentration where no significant effect is observed; and the term “LOEC” may refer to the lowest concentration where some significant effect is observed.

In an embodiment, where the wellbore servicing fluid or various components thereof are deemed acceptable for usage, the wellbore servicing fluid or component may be made available for usage. For example, a provider or manufacturer may package the fluid and/or fluid component for distribution and usage by an end user. Such a provider or manufacturer may provide instructions, information, and/or recommendations (e.g., on, within, or included with the product) for the safe and proper usage of the fluid or fluid component. For example, such instructions, information, or recommendations may include safe and effective concentrations for usage, geographical or other usage restrictions, proposed risk avoidance measures, proposed clean-up procedures, safety and/or environmental impact ratings, or the like.

In an embodiment, where the wellbore servicing fluid or various components thereof are deemed acceptable for usage, the wellbore servicing fluid, alternatively, the acceptable wellbore servicing fluid components, may be utilized in a wellbore servicing operation. In such an embodiment, the wellbore servicing operation may comprise a drilling operation, a wellbore clean-out operation, a completion and/or cementing operation, an acidizing operation, a perforating operation, a fracturing or other stimulation operation, a workover operation, a shut-in or well-kill operation, any other like, suitable operation, as will be recognized by one of skill in the art viewing this disclosure, or combinations thereof.

In an embodiment, the wellbore servicing fluid may be prepared at the site of such a servicing operation (e.g., at the wellhead). For example, the wellbore servicing fluid and/or component may be mixed (e.g., via the operation of one or more blenders) one or more additional component in suitable amounts to yield a servicing fluid of a desired character. In an alternative embodiment, the wellbore servicing fluid or component may be prepared off-site and transported to the work site.

In an embodiment, the prepared wellbore servicing fluid may be conveyed into the wellbore and/or into the subterranean formation. For example, the prepared fluid present at the work site may be conveyed via the operation of one or more pumps, compressors, or the like, through flowlines (e.g., manifolds, tubing, etc.) into the wellbore. As will be appreciate by one of skill in the art the wellbore servicing fluid may be conveyed at a suitable rate and/or pressure, as may depend upon the particular servicing operation being performed. In addition, the wellbore servicing fluid may be circulated through the wellbore, introduced into the formation (e.g., a fracture or perforation within the formation), or to a predetermined depth within the wellbore.

In various embodiments, the wellbore servicing operation may be directed to a wellbore penetrating a subterranean formation beneath dry land, alternatively, to a subterranean formation beneath a body of water.

The exemplary chemicals, fluids, and/or additives disclosed herein may directly or indirectly affect one or more components or pieces of equipment associated with the preparation, delivery, recapture, recycling, reuse, and/or disposal of the disclosed chemicals, fluids, and/or additives. For example, the disclosed chemicals, fluids, and/or additives may directly or indirectly affect one or more mixers, related mixing equipment, mud pits, storage facilities or units, fluid separators, heat exchangers, sensors, gauges, pumps, compressors, and the like used generate, store, monitor, regulate, and/or recondition the exemplary chemicals, fluids, and/or additives. The disclosed chemicals, fluids, and/or additives may also directly or indirectly affect any transport or delivery equipment used to convey the chemicals, fluids, and/or additives to a well site or downhole such as, for example, any transport vessels, conduits, pipelines, trucks, tubulars, and/or pipes used to fluidically move the chemicals, fluids, and/or additives from one location to another, any pumps, compressors, or motors (e.g., topside or downhole) used to drive the chemicals, fluids, and/or additives into motion, any valves or related joints used to regulate the pressure or flow rate of the chemicals, fluids, and/or additives, and any sensors (i.e., pressure and temperature), gauges, and/or combinations thereof, and the like. The disclosed chemicals, fluids, and/or additives may also directly or indirectly affect the various downhole equipment and tools that may come into contact with the chemicals/fluids such as, but not limited to, drill string, coiled tubing, drill pipe, drill collars, mud motors, downhole motors and/or pumps, floats, MWD/LWD tools and related telemetry equipment, drill bits (including roller cone, PDC, natural diamond, hole openers, reamers, and coring bits), sensors or distributed sensors, downhole heat exchangers, valves and corresponding actuation devices, tool seals, packers and other wellbore isolation devices or components, and the like.

ADDITIONAL DISCLOSURE

The following are non-limiting, specific embodiments in accordance with the present disclosure:

A first embodiment, which is a method of assessing a wellbore servicing fluid or a component thereof comprising:

providing a plurality of test organisms;

dividing the plurality of test organisms into a control group and at least one test group;

subjecting the at least one test group to the wellbore servicing fluid or component thereof for a predetermined duration, wherein subjecting the at least one test group to the wellbore servicing fluid or component thereof comprises:

-   -   providing a wellbore fluid testing system comprising a plurality         of containers and a cover;     -   placing at least a portion of the control group within a first         container;     -   placing at least a portion of the at least one test group within         a second container; and     -   covering the first container and the second container with the         cover; and     -   assessing the acceptability of the wellbore servicing fluid or         component thereof.

A second embodiment, which is the method of the first embodiment, wherein the wellbore servicing system comprises from about 15 to about 30 containers, wherein the containers are arranged in a plurality of columns, each of the columns comprising two or more containers.

A third embodiment, which is the method of one of the first through the second embodiments, wherein the containers comprise a volume of from about 0.5 liter to about 2 liters.

A fourth embodiment, which is the method of one of the first through the third embodiments, wherein the wellbore servicing system comprises 18 containers.

A fifth embodiment, which is the method of the fourth embodiment, wherein the containers are arranged in six columns, each of the six columns comprising three containers.

A sixth embodiment, which is the method of the fifth embodiment, wherein the control group is placed in each of the containers of a first column.

A seventh embodiment, which is the method of the sixth embodiment, wherein the at least one test group is placed in the containers of at least a second column.

An eighth embodiment, which is the method of one of the first through the seventh embodiments, wherein the cover comprises a plurality of holes, each of the plurality holes being configured to allow access to each of the plurality of containers.

A ninth embodiment, which is the method of the eighth embodiment, wherein the wellbore servicing system further comprises a plurality of aeration tubes inserted through the plurality of holes.

A tenth embodiment, which is the method of one of the first through the ninth embodiments, wherein the cover comprises a hinge joining two portions of the cover.

An eleventh embodiment, which is the method of one of the first through the tenth embodiments, wherein the wellbore servicing system further comprises a lift system.

A twelfth embodiment, which is the method of the eleventh embodiment, wherein the test organisms are introduced within an aqueous solution.

A thirteenth embodiment, which is the method of the twelfth embodiment, wherein the aqueous solution comprises a sedimentary material.

A fourteenth embodiment, which is the method of the thirteenth embodiment, wherein the aqueous solution comprises a salinity of from about 15 ppt. to 40 ppt.

A fifteenth embodiment, which is the method of one of the first through the fourteenth embodiments, wherein the at least one test group comprises at least two test groups, wherein, in each of the at least two test groups, the test organisms are subjected to the wellbore servicing fluid or component thereof at varying concentrations.

A sixteenth embodiment, which is the method of one of the first through the fifteenth embodiments, wherein the at least one test group comprises at least two test groups, wherein, in each of the at least two test groups, the test organisms are subjected to a different component of the wellbore servicing fluid.

A seventeenth embodiment, which is the method of one of the first through the sixteenth embodiments, wherein the test organism comprises a member of the order Mysida.

An eighteenth embodiment, which is the method of one of the first through the seventeenth embodiments, wherein the predetermined duration is from about 24 hours to about 10 days.

A nineteenth embodiment, which is the method of one of the first through the eighteenth embodiments, wherein the predetermined duration is about 24 hours to about 96 hours.

A twentieth embodiment, which is the method of one of the first through the nineteenth embodiments, wherein the wellbore servicing fluid or a component thereof comprises a drilling fluid, a perforating fluid, a fracturing fluid, an acidizing fluid, a cementitious composition, or a component thereof.

At least one embodiment is disclosed and variations, combinations, and/or modifications of the embodiment(s) and/or features of the embodiment(s) made by a person having ordinary skill in the art are within the scope of the disclosure. Alternative embodiments that result from combining, integrating, and/or omitting features of the embodiment(s) are also within the scope of the disclosure. Where numerical ranges or limitations are expressly stated, such express ranges or limitations should be understood to include iterative ranges or limitations of like magnitude falling within the expressly stated ranges or limitations (e.g., from about 1 to about 10 includes, 2, 3, 4, etc.; greater than 0.10 includes 0.11, 0.12, 0.13, etc.). For example, whenever a numerical range with a lower limit, Rl, and an upper limit, Ru, is disclosed, any number falling within the range is specifically disclosed. In particular, the following numbers within the range are specifically disclosed: R=Rl+k*(Ru-Rl), wherein k is a variable ranging from 1 percent to 100 percent with a 1 percent increment, i.e., k is 1 percent, 2 percent, 3 percent, 4 percent, 5 percent, . . . , 50 percent, 51 percent, 52 percent, . . . , 95 percent, 96 percent, 97 percent, 98 percent, 99 percent, or 100 percent. Moreover, any numerical range defined by two R numbers as defined in the above is also specifically disclosed. Use of the term “optionally” with respect to any element of a claim means that the element is required, or alternatively, the element is not required, both alternatives being within the scope of the claim. Use of broader terms such as comprises, includes, and having should be understood to provide support for narrower terms such as consisting of, consisting essentially of, and comprised substantially of. Accordingly, the scope of protection is not limited by the description set out above but is defined by the claims that follow, that scope including all equivalents of the subject matter of the claims. Each and every claim is incorporated as further disclosure into the specification and the claims are embodiment(s) of the present invention. 

What is claimed is:
 1. A method of assessing a wellbore servicing fluid or a component thereof comprising: providing a plurality of test organisms; dividing the plurality of test organisms into a control group and at least one test group; subjecting the at least one test group to the wellbore servicing fluid or component thereof for a predetermined duration, wherein subjecting the at least one test group to the wellbore servicing fluid or component thereof comprises: providing a wellbore fluid testing system comprising a plurality of containers and a cover; placing at least a portion of the control group within a first container; placing at least a portion of the at least one test group within a second container; and covering the first container and the second container with the cover; and assessing the acceptability of the wellbore servicing fluid or component thereof.
 2. The method of claim 1, wherein the wellbore servicing system comprises from about 15 to about 30 containers, wherein the containers are arranged in a plurality of columns, each of the columns comprising two or more containers.
 3. The method of claim 1, wherein the containers comprise a volume of from about 0.5 liter to about 2 liters.
 4. The method of claim 1, wherein the wellbore servicing system comprises 18 containers.
 5. The method of claim 4, wherein the containers are arranged in six columns, each of the six columns comprising three containers.
 6. The method of claim 5, wherein the control group is placed in each of the containers of a first column.
 7. The method of claim 6, wherein the at least one test group is placed in the containers of at least a second column.
 8. The method of claim 1, wherein the cover comprises a plurality of holes, each of the plurality holes being configured to allow access to each of the plurality of containers.
 9. The method of claim 8, wherein the wellbore servicing system further comprises a plurality of aeration tubes inserted through the plurality of holes.
 10. The method of claim 1, wherein the cover comprises a hinge joining two portions of the cover.
 11. The method of claim 1, wherein the wellbore servicing system further comprises a lift system.
 12. The method of claim 11, wherein the test organisms are introduced within an aqueous solution.
 13. The method of claim 12, wherein the aqueous solution comprises a sedimentary material.
 14. The method of claim 13, wherein the aqueous solution comprises a salinity of from about 15 ppt. to 40 ppt.
 15. The method of claim 1, wherein the at least one test group comprises at least two test groups, wherein, in each of the at least two test groups, the test organisms are subjected to the wellbore servicing fluid or component thereof at varying concentrations.
 16. The method of claim 1, wherein the at least one test group comprises at least two test groups, wherein, in each of the at least two test groups, the test organisms are subjected to a different component of the wellbore servicing fluid.
 17. The method of claim 1, wherein the test organism comprises a member of the order Mysida.
 18. The method of claim 1, wherein the predetermined duration is from about 24 hours to about 10 days.
 19. The method of claim 1, wherein the predetermined duration is about 24 hours to about 96 hours.
 20. The method of claim 1, wherein the wellbore servicing fluid or a component thereof comprises a drilling fluid, a perforating fluid, a fracturing fluid, an acidizing fluid, a cementitious composition, or a component thereof. 